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Record 11-1071 Record Level SC Proposal Project Manager David Tuttle Record Sub-Type Revision Pages Subject BPV I; PL-54 Pressure Relief Valves Proposal Add new paragraph PL-54 to Part PL, Requirements for Locomotive Boilers, in BPVC Section I, Rules for Construction of Power Boilers. Explanation Subgroup on Locomotive Boilers (BPV) has the task of establishing rules for locomotive boilers within Section I. New paragraph PL-54 of the new part contains rules for the pressure relief valves. Summary of Changes New paragraph to add pressure relief valve requirements for locomotive boilers. Item History Sub-Tier Committees Involved BPV SC-SVR BPV SC-SVR SGGR Latest Ballot Information Ballot: 12-2731 Ballot Level: Subcommittee Final Record Status :Disapproved Date Opened: 11/30/2012 Date Closed: 01/14/2013 205
Item 11-1071: Section I Draft of PL-54 Safety Relief Valves SC-SVR History June, 2011 This item was opened in response to a request from Mr. Linn W. Moedinger, chairman of BPV I SG on Locomotive Boilers, to review the draft of some wording for steam locomotives, part of which includes safety valve language August 9, 2011 - This item involves pressure relief devices for locomotive boilers. Mr. Tuttle reported that there will be a new subsection of Section I for locomotive boilers. In the old days locomotives had to follow the same requirements as stationary boilers. Various task groups were formed; they have drafted requirements including some on safety relief. The draft is not ready for ballot, it is the original proposal from Section I but it is Mr. Tuttle s intention to revise this before the TGs review. At this point, the original proposal is uploaded and Mr. Tuttle is open to all suggestions regarding it and is looking for the SC s input. Mr. Tuttle will try to get a proposal together to be balloted to SVR before it moves to Section I. November 8, 2011 Mr. Tuttle reported that there is a new part to Section I which is being written, it consists of rules for locomotive boilers. There is a portion of this for overpressure protection which was brought to this committee for consideration. At the SG-GR meeting, the draft proposal was reviewed. Mr. Tuttle will be collecting comments from the SG on this and will be revising the proposal accordingly for ballot before the next meeting. February 7, 2012 Mr. Ball reported for Mr. Tuttle that this item was balloted to the SG for a part PL-54 which is PRVs for locomotives. This is part of a larger item going forward in BPV I, there was a SG ballot which was closed. All of the comments need to be incorporated into the proposal and will be sent for a second consideration ballot to the Subgroup. May 15, 2012 Mr. DeMichael reported that this has been through SC-SVR SG-GR for ballot with comments from Mr. Moedinger. Alan will send an email to Mr. Moedinger regarding his concerns. The secretary will initiate a ballot to SC-SVR and will include BPV I SG-GR for review and comment. August 14, 2012 Mr. Tuttle reviewed the comments that were received on the last ballot as well as his responses. He will be modifying the proposal based on the comments; all the needed changes are editorial. He will upload the proposal and then determine if it should be a new first consideration ballot or a recirculation ballot. Mr. West requested that we continue to have a dialogue with Mr. Moedinger so that we can make sure that what SVR approves will be usable. The secretary was instructed to keep this item in SC-SVR so that it can be discussed at the November meeting. 206
Item 11-1071: Section I Draft of PL-54 Safety Relief Valves [Continued] November 6, 2012 Mr. Tuttle reported that he has revised the proposal, as shown in the minutes, to satisfy the needs as described by Mr. Moedinger from the August 2012 meeting. The PM will send an email to the secretary when the item is ready for ballot. February 12, 2013 Mr. DeMichael reported that there was a subcommittee ballot that closed and there was a considerable amount of discussion regarding the negatives which were associated with removing some of the material requirements for the valves. Mr. Moedinger was present at the subgroup meeting and the SG provided some input to him.mr. Moedinger needed to understand some of the things they were concerned about when writing the codes and they needed to better understand the equipment that he is dealing with. Mr. Moedinger developed a schematic which is shown on pages 320. Mr. Ball is going to be putting together a list of material requirements that, in his mind, should be set in place to be acceptable. The question on the table at this time is whether this committee is prepared at this time to accept an accumulation test in place of a capacity test. SG-GR is still working on the current proposal to address the comments from the last ballot. August 13, 2013 Mr. Ball reported that this item was balloted to SG-GR with SVR added for comment. The comments need to be addressed before the next round of balloting. October 29, 2013-207
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Item 11-1071 10-16-13 J. F. Ball proposal for Overpressure Protection for Locomotives Editorial changes: Safety valve changed to pressure relief valve, blowback changed to blowdown Technical changes: Gives two methods of determining capacity, refers to applicable requirements from part PG while acknowledging differences needed for locomotive valves. PL-54 Pressure Relief Valves PL-54.1 Every locomotive boiler shall be equipped with at least two pressure relief valves, the capacity of which shall be sufficient to discharge all the steam that can be generated by the boiler without allowing the pressure to rise more than 5 percent above the highest set pressure at which any valve is set, and in no case more than 5 percent above the maximum allowable working pressure. At least one valve shall have a marked set pressure below the maximum allowable working pressure by the tolerance allowed in the table in PG-72.2. The other valve or valves may have a marked set pressure that is higher than the lowest set valve, with the highest valve setting not to exceed 6 PSI (40 kpa) above MAWP. Note: Often Steam Locomotive Style pressure relief valves that are designed to act as both an overpressure protection device and a pressure regulating device are used for this service. PL-54.2 Mechanical Requirements Pressure relief valves shall conform to the requirements of PG-73.1 and PG-73.2 with the following exceptions or additions. PL-54.2.1 Pressure relief valves shall be of the top discharge type. PL-54.2.2 A lifting device as specified in PG-73.2.4 is not required. PL-54.3 Material requirements. Material requirements shall be in accordance with PG-73.3. PL-54.4 Capacity Certification Pressure relief valves shall be certified for capacity as required by paragraphs PG-69 and PG-73.4. PL-54.4.1 As an alternative to capacity certification, the Initial Verification procedure of paragraph PL-54.xxx may be used to determine if an adequate amount of capacity is available from the installed pressure relief valves. PL-54.5 Production Testing All pressure relief valves shall be production tested in accordance with paragraphs PG-73.5. The operation verification test in PL-54.xx may be considered as the set pressure test required by paragraph PG-73.5.2 when performed by the valve manufacturer. PL-54.6 Valve Stamping and Marking Each pressure relief valve shall be marked in accordance with paragraph PG-110 with the following clarifications. 1. If an accumulation test will be used to determine the adequacy of the valve capacity in lieu of capacity certification testing, no capacity shall be applied to the stamping or nameplate. By Accum. Test shall be marked instead of a capacity value. 2. Each valve shall be serialized by the valve Manufacturer to allow for referencing on the boiler data report (See PL-54.xxx) PL-54.7 Sizing and Initial Verification of Steam locomotive Style Pressure Relief Valves 209
1. Required pressure relief valve capacity may be determining the maximum designed steaming output of the boiler by using calculations as outlined in PL-XXX. Capacity certified pressure relief valves shall then be selected with a total rated capacity equal to or greater than the required capacity. 2. Where the valves are not capacity certified, or where an existing valve will be used on a new boiler, an accumulation test may be used to verify that the installed capacity is adequate. a. Accumulation testing may be hazardous because the boiler is being run at maximum fire, and pressure relief valve capacity has not been verified. It should be done only under carefully controlled conditions by trained knowledgeable personnel. b. Boiler pressure shall be continuously monitored by both an operating gage and a calibrated test gage. c. The pressure relief valves shall first have been set in accordance with the operational verification test requirements. d. The accumulation test shall be performed by shutting off all other steam-discharge outlets from the boiler and forcing the fire to the maximum. e. The locomotive shall be secured from movement, cylinder and valve vents blocked open, and throttle unsecured. f. Should the pressure approach the limits specified in Part PL-54.1 the throttle shall be opened enough to relieve the pressure and the fire reduced to prevent further accumulation of pressure. Corrective action to supply additional capacity shall then be taken. g. The safety relief valves shall be sufficient to prevent an excess pressure beyond that specified in Part PL-54.1. h. Where the pressure relief valve capacity has been verified by an accumulation test, the valves shall be used only on the boiler on which they were tested. The valve identification numbers and set pressures shall be recorded on the data report for that specific boiler by the boiler manufacturer. PL-54.8 Operational verification of steam locomotive pressure relief valves 1. Operational verification of steam locomotive pressure relief valves may be accomplished by testing the valves on a steam test stand. 2. As an alternative, the valves may be set on the locomotive boiler. a. A calibrated test gage shall be used in addition to the boiler operating gage. b. The boiler pressure shall be brought up at a controlled rate and the valves alternately set until the lowest set valve is set to open at the tolerance in table PG-72.2 with a blowdown of not less than 2 percent of MAWP. c. The low set valve may then be gagged, and the higher set valve or valves shall then be set to open within the set pressure tolerance in table PG-72.2. The blowdowns for the higher set valves shall be set such that the blowdown is greater than 2% of the MAWP, and the valves will close below the lowest set valve set pressure. 210
Record 11-2105 Record Level SC Proposal Project Manager Jeramy W. Dickson Record Sub-Type Revision Pages Subject BPV I, Supercritical Capacity Calculations for Applications outide of Tables PG-69.2.3 and PG-39.2.3M Proposal Delete the last paragraph of PG-69.2.3 and replace with language and formulas that allows the use of the isentropic flow equations for the capacity calculation. Explanation In the 2010 Edition of ASME Section I, Tables PG-69.2.3 and PG-69.2.3M were introduced for the supercritical capacity certification for PRVs. Due to the simplification of the that Tables for pressure and temperature increments of 50 units for publication, certain applications cannot obtain a correction factor (i.e., cannot be sized, thus not code stamped). Example: application pressure of 4475 psig at a relieving temperature of 770 of. The combination of flowing pressure (4624 psia) and temperature will not yield a correction factor. Allow the use of the isentropic flow equation for applications outside the scope of the Ksc correction factor tables. Summary of Changes Item History Sub-Tier Committees Involved BPV SC-SVR SGGR Latest Ballot Information 211
Item 11-2105; BPV I; Supercritical Capacity Calculation for applications outside of Tables PG- 69.2.3 and PG-69.2.3M SC-SVR History November 8, 2011 Mr. Tuttle reported that this request came from Jeramy Dickson. In the 2010 Edition of ASME Section I, Tables PG-69.2.3 and PG-69.2.3M were introduced for the supercritical capacity certification for PRVs. Due to the simplification of the that Tables for pressure and temperature increments of 50 units for publication, certain applications cannot obtain a correction factor (i.e., cannot be sized, thus not code stamped). Example: application pressure of 4475 psig at a relieving temperature of 770 o F. The combination of flowing pressure (4624 psia) and temperature will not yield a correction factor. Allow the use of the isentropic flow equation for applications outside the scope of the K sc correction factor tables. February 7, 2012 Mr. Dickson reported that this item has to do with the BPV I Table for the K fc Factor and the fact that one cannot interpolate certain sections. Mr. Tuttle has provided Mr. Dickson the information from record #07-1148 which was for the development of this table. Mr. Dickson will be using this information to determine the course of action for this item. May 15, 2012 Mr. Cox reported that this is no proposal yet; Jeramy Dickson is working on it. August 14, 2012 Mr. Cox reported that they are still working on this proposal. November 6, 2012 Mr. Cox reported that work is in progress. February 12, 2013 - Mr. Hart reported that there has not been much progress on this, they will give the PM a chance to move it forward otherwise they will appoint a new PM at the next meeting. August 13, 2013 Mr. Nutter reported that no activity has been done on this in quite some time; the current proposal allows the use of isothermal equations for supercritical values. October 29, 2013-212
Record 12-450 Record Level SC Proposal Project Manager James Pillow Record Sub-Type Revision Pages Subject Section I, Revision of PG-73.7.1, PEB-18.5.1, and A-360 - Certified Individual to Meet QAI-1 Requirements Proposal Revise PG-73.7.1, PEB-18.5.1, and A-360 as per the attached markup Explanation In the 2003 addenda, Section I installed the rules for Certified Individuals (CI) in PG-73 and Part PEB. This action was made to meet the Codes and Standards Polciy requirements of CSP-53. At that time, these were standalone rules. Since their original publication, ASME QAI-1 has provided specific rules for Certified Individuals in Part 8 for the CI. Purpose: to switch the qualification rules for Certified Individual from the text of Section I to Part 8 of current ASME QAI-1. Copies of CSP-53 and QAI-1, Part 8 are included in the Committee Correspondence section of this record. Note that QAI-1, Part 8 now requires the CI to successfully complete the National Board training. Summary of Changes Revise PG-73.7.1, PEB-18.5.1, and A-360 Item History BPV I, 8/15/13: It was noted that this proposal was balloted by the SC-SVR and received seven negatives. The Secretary was requested to upload Part 8 of QAI-1 into the background file for this item. BPV I, 8/16/12: Motion was unanimously voted approved for the Secretary to refer this item to the SC-SVR for their review and recommendation. Sub-Tier Committees Involved BPV SC-I Genl Req SG BPV SC-SVR Latest Ballot Information Ballot: 13-118 Ballot Level: Subcommittee Final Record Status :Disapproved Date Opened: 01/14/2013 Date Closed: 02/21/2013 213
Item 12-450: Section I, Revision of PG-73.7.1, PEB-18.5.1, and A-360 - Certified Individual to Meet QAI-1 Requirements SC-SVR History November 6, 2012 This item was transferred from BPV I to SC-SVR. Alan, Dennis and Colleen will discuss and decide on how this item should be handled within SVR. February 12, 2013 This item is still out for ballot, the secretary will leave it open until the end of the week. August 13, 2013 Mr. West reported that SVR voiced its disapproval on several ballots that were sent to other committees for vote. When the proposal reached balloting for BPV I, SVR was added for review and comment. This ballot was disapproved and will be discussed at the SG-GR meeting tomorrow. Any members who are available to attend that meeting are asked to do so to support the issues SVR has with this proposal. October 29, 2013-214
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Current Text: PG 73.7.1 Requirements for the Certified Individual (CI). The CI shall (a) be an employee of the manufacturer or assembler (b) be qualified and certified by the manufacturer or assembler. Qualifications shall include as a minimum (1) knowledge of the requirements of this Section for the application of the Certification Mark with the "V Designator (2) knowledge of the manufacturer's or assembler's quality program (3) training commensurate with the scope, complexity, or special nature of the activities to which oversight is to be provided (c) have a record, maintained and certified by the manufacturer or assembler, containing objective evidence of the qualifications of the CI and the training program provided. PG 73.7.2 Duties of the Certified Individual (CI);, (a) The CI shall (a) verify that each item to which the Certification Mark with the "V" Designator is applied has a current capacity certification and meets all applicable requirements of this Section (b) review documentation for each lot of items to be stamped to verify, for the lot, that requirements of this Section have been completed (c) sign the Certificate of Conformance, Form P 8, prior to release of control of the pressure relief valves PG 73.7.3 Certificate of Conformance, Form P 8. (a) The Certificate of Conformance, Form P 8, shall be filled out by the manufacturer or assembler and signed by the Certified Individual. Multiple duplicate pressure relief valves may be recorded as a single entry, provided the valves are identical and are produced in the same lot. (b) The manufacturer's or assembler's written quality control program shall include requirements for completion of Certificates of Conformance, Form P 8, and retention, by the manufacturer or assembler, for a minimum of 5 years. Proposed change: PG 73.7.1 Requirements for the Certified Individual (CI). The CI, meeting the requirements of ASME QAI 1, shall 216
Current Text: Proposed Change: PEB-18.5 Those Manufacturers and Assemblers providing an equivalent examination of completed electric boilers when final inspection is not witnessed by the Authorized Inspector (see PEB-18.1), shall provide oversight by a Certified Individual (CI). PEB-18.5.1 A Certified Individual (CI) shall be an employee of the Manufacturer or Assembler and shall be qualified and certified by the Manufacturer or Assembler. Qualifications shall include as a minimum (a) knowledge of the requirements of this Section for the application of Certification Marks (b) knowledge of the Manufacturer's quality program (c) training commensurate with the scope, complexity, or special nature of the activities to which oversight is to be provided PEB-18.5.1 A Certified Individual (CI), meeting the requirements of ASME QAI 1, shall be an employee of the Manufacturer or Assembler and shall be qualified and certified by the Manufacturer or Assembler. Qualifications shall include as a minimum The Manufacturer or Assembler shall maintain a record containing objective evidence of the Certified Individual's qualifications, training, and certification. PEB-18.5.2 The duties of a Certified Individual (CI) shall be to assure that each use of the Certification Mark as permitted in PEB-18.3.3 is in accordance with the requirements of this Section and is documented on the Certificate of Conformance on Form P-2A, Manufacturers Data Report for All Types of Electric Boilers. The CI shall also (a) verify that each electric boiler, to which a Certification Mark is applied, meets all applicable requirements of this Section (b) sign the Certificate of Conformance, Form P-2A, prior to release of control of the boiler 217
Revise Table A 360 as follows: QAI 1 Latest Edition Qualifications for Certified Individual and Authorized Inspection 218
Record 12-897 Record Level SC Proposal Project Manager David Tuttle Record Sub-Type Revision Pages Subject BPV I - 2; Overpressure Protection Proposal New Part 9, Overpressure Protection for proposed Division 2 to Section I. Explanation A new standalone division or appendix resulting from the work of Task Group on Modernization of Section I will require a part for Overpressure Protection, similar to Part 9 of Section VIII Division 2. This proposal is for the Part 9 that will be in the new section. Summary of Changes Proposed new Part 9 for proposed new Division 2 to Section I. Item History Sub-Tier Committees Involved BPV SC-SVR SGGR Latest Ballot Information 219
Item 12-897: Section I-2; Overpressure Protection SC-SVR History May 21, 2012 This item was opened for SC-SVR review and comment on Part 9, Overpressure Protection for proposed Division 2 to Section I. August 14, 2012 Mr. Tuttle reported that this item is the draft for the overpressure protection portion for BPV I-2. The overpressure protection portion of this has been drafted; Mr. Tuttle will send the draft to the task group for review and comment before any ballots are initiated. November 6, 2012 Mr. Tuttle reported that this will be a stand-alone document and will be similar to BPV VIII-2. There is a PT in place. The current proposal does not change section I but reorganizes the rules. The PT will hold a meeting during the February BCW. February 12, 2013 Mr. DeMichael reported that they are planning to hold a teleconference sometime in the near future, the proposal as shown in the agenda takes the existing rules and reorganizes them; the new section will be a design by analysis section. Mr. Tuttle is open to suggestions even if you are not a member of the TG. August 13, 2013 Mr. Ball reported for Mr. Tuttle that there is a task group which is still trying to determine whether it will be a new book or if it will be added as an appendix to the current BPV I book. October 29, 2013-220
PART 9 OVERPRESSURE PROTECTION 9.1 General Requirements 221 a) This Part provides the requirements for pressure relief devices used to protect against overpressure in power boilers and high-pressure, high-temperature water boilers constructed to the requirements of this Division. It establishes the type, quantity, and settings of acceptable devices and the relieving capacity requirements for the applicable boilers. Also provided are the requirements for the material, design, construction, and production testing of pressure relief valves and the requirements, including capacity certification testing, for obtaining and using the Code symbol stamp for pressure relief devices. In addition, this Part provides the requirements for installation of these pressure relief devices. b) {PG-73.1.1} c) {PG-73.1.2} d) {PG-73.1.3} e) {PG-73.1.4} 9.1.1 Protection Against Overpressure a) Applicable Vessels 1) All boilers having more than 500 sq ft of bare tube water-heating surface. 2) All electric boilers having a power input of more than 1100kW. 3) All boilers with combined bare tube and extended water-heating surface exceeding 500 sq ft. 4) All organic fluid vaporizer generators.
4) Any economizer which may be shut off from the boiler, thereby permitting the economizer to become a fired pressure vessel b) Minimum Number of Pressure Relief Valves Required {PG-67.1} c) Determination of the Number of Pressure Relief Valves 1) {PG-70.1} 222 2) For a forced-flow steam generator with no fixed steam and waterline, equipped with automatic controls and protective interlocks responsive to steam pressure, pressure relief valves may be provided in accordance with the above paragraphs, or one or more power-actuated pressure relieving valves shall be provided in direct communication with the boiler when the boiler is under pressure and shall receive a control impulse to open when the maximum allowable working pressure at the superheater outlet, as shown in the master stamping (PG-106.3) is exceeded. 3) Any economizer that may be shut off from the boiler, thereby permitting the economizer to become a fired pressure vessel, shall have one or more pressure relief valves. 4) {1 st sentence of PG-68.1} 5) Every isolable superheater that may be shut off from the boiler and permit the superheater to become a fired pressure vessel and all nonintegral separately fired superheaters shall have one or more safety valves. 6) {PEB-15.1} 9.1.2 Relieving Capacity Requirements a) Pressure Relief Valve Capacity for Each Boiler {PG-67.2} b) Minimum Relieving Capacity Required for Pressure Relief Valves
{PG-67.2.1} c) Minimum Relieving Capacity Required for Waste Heat Boilers {PG-67.2.2} d) Minimum Relieving Capacity Required for Electric Boilers {First sentence of PEB-15.2} e) Minimum Relieving Capacity Required for High Temperature Water Boilers {PG-67.2.4} f) Pressure Relief Valves for Organic Fluid Vaporizers {PVG-12.5} 223 g) Minimum Relieving Capacity Required for Organic Fluid Vaporizers {PVG-12.6}?) Minimum Relieving Capacity Required for Miniature Boilers {PMB-15.2} h) Minimum Relieving Capacity Required for Economizers {PG-67.2.6} i) Minimum Relieving Capacity for Forced Flow Steam Generators {2 nd sentence of PG-67.4.1} j) Minimum Relieving Capacity for Pressure Relief Valves for Forced Flow Steam Generators {1 st and 2 nd sentence of PG-67.4.2} k) Total Capacity of Pressure Relief Valves for Forced Flow Steam Generators {PG-67.4.3}
i) Control to Maintain Steam Pressure, Modulate Firing Rates, and Modulate Feedwater Flow for Forced Flow Steam Generators 1) Boiler Steaming Capacity for Forced Flow Steam Generators {PG-67.4.3.1} 2) Boiler Automatic Devices for Forced-Flow Steam Generators {PG-67.4.3.2} {Fig. PG-67.4, Requirements for Overpressure Protection Forced-Flow Steam Generator {PG-67.4.3.2.1} ii) Control to Override Fuel Rate Flow for Forced Flow Steam Generators {PG-67.4.3.2.2} 224 iii) Trip-Actuating Mechanism to Stop Flow of Fuel and Feedwater for Forced Flow Steam Generators {PG-67.4.3.2.3} 3) Spring Loaded Pressure Relief Valves for Forced Flow Steam Generators {PG-67.4.3.3} 4) Spring Loaded Pressure Relief Valve Device to Stop Fuel Flow and Feedwater for Forced Flow Steam Generators {PG-67.4.3.4} 5) Power Supply for All Controls for Forced Flow Steam Generators {PG-67.4.3.5} t) Stop Valves in Forced Flow Steam Generators {PG-67.4.4} 1) {PG-67.4.4.1}
w) Determination of Number and Size of Pressure Relief Valves for the Boiler Based on Discharge Capacity of Safety Valves(s) on Attached Superheater 2) {PG-67.4.4.2} u) Pressure Recording Device for Forced Flow Steam Generators {PG-67.4.5} v) Determination of Relieving Capacity in Superheaters {3 rd sentence of PG-68.1} {PG-68.2} x) Determination of Pressure Relief Valves for Independently Fired Superheaters and Reheaters 225 The total discharge capacity of the pressure relief valve(s) shall have a discharge capacity equal to 6 lb/ft 2 (29 kg/m 2 ) of steam per hour, using the superheater surface measure on the side exposed to the hot gases. As an alternative the Manufacturer may also calculate the minimum pressure relief valve discharge capacity in lb (kg) of steam per hour from the maximum expected heat absorption (as determined by the Manufacturer) in Btu/hr (W), divided by 1,000 (646). In the case of electrically heated superheaters, the pressure relief valve capacity shall be based upon 3½ lb (1.6 kg)/hr/kw input. For reheaters, the total discharge capacity of the pressure relief valve(s) shall at least equal the maximum steam flow of the reheater. y) Determination of Pressure Relief Valve Discharge Capacity for Organic Vaporizers {PVG-12.4} 9.1.3 Set Pressure Requirements a) General Requirements {1 st, 2 nd and 3 rd sentences of PG-67.3}
d) Forced-Flow Steam Generators with No Fixed Steam and Waterline, Equipped with Automatic Controls and Protective Interlocks Responsive to Steam Pressure The pressure drop upstream of each pressure relief valve shall be considered in the determination of set pressure of that valve. b) High-Temperature Water Boilers {4th sentence of PG-67.3, including footnote} c) Economizers {Last sentence of PG-67.3} {Last sentence of PG-67.4.2} e) Superheaters 226 9.1.4 Permissible Overpressure a) General Requirements {PG-67.2} b) Forced-Flow Steam Generators with No Fixed Steam and Waterline, Equipped with Automatic Controls and Protective Interlocks Responsive to Steam Pressure {Last sentence of PG-67.4.2} 9.2 Certification Requirements a) Requirements for Applying Code Symbol {PG-69.1} b) Requirements for Design Changes {PG-69.6}
c) Test Facilities {PG-69.1.2} d) Test Media {PG-69.1.1} e) General Test Requirements {PG-69.1.4} f) Test Requirements for Organic Vaporizers {1 st sentence of PVG-12.5, up to first comma} g) Requirements for Determination of Relieving Capacity 227 {PG-69.2} 1) Three Valve Method Capacity Certification Test {PG-69.2.1} 2) Four Valve Method Capacity Certification Test {PG-69.2.2} 3) Coefficient of Discharge Method {PG-69.2.3} h) Capacity Certification for Power-Actuated Pressure Relief Valves {1 st three sentences of last paragraph of PG-67.4.1} i) Pressure Relief Valves for Power-Actuated Pressure Relief Valves {2 nd paragraph of PG-67.5} j) Requirements for Applying the Code Symbol to Power-Actuated Pressure Relieving Valves
{PG-69.3} k) Capacity Test Reports {PG-69.1.3, with footnote} 9.3 Marking and Stamping a) General Requirements for Pressure Relief Valves {PG-110} b) Requirements for Power-Actuated Pressure Relief Valves {PG-69.4} c) Requirements of Organic Vaporizers 228 {PVG-12.5} 9.4 Material, Design and Construction Requirements a) General Design Minimum Requirements {PG-73.2.1} {1 st and 2 nd paragraphs of PG-67.5} b) Requirements for Pressure Relief Valves Over 3 Inch in Size {PG-73.2.11} c) Requirements for Guiding Arrangements {PG-73.2.2} d) Requirements for Spring Design
{PG-73.2.3} e) Requirements for Lifting Devices {PG-73.2.4} f) Requirements for Seats of Pressure Relief Valves {PG-73.2.5} g) Requirements for a Body Drain {PG-73.2.6} h) Requirements for Body Design 229 {PG-73.2.7} i) Requirements for Screwed Inlet or Outlet Connections {PG-73.2.8} j) Requirements for Sealing All External Adjustments {PG-73.2.9} k) Valve Design Review {PG-73.6} l) Minimum Requirements for Design of Pressure Relief Valves for High-Temperature Water Boilers {Last paragraph of PG-67.5} {Last paragraph of PG-71.3}
{3 rd sentence of PG-73.2.4} m) Minimum Requirements for Design of Safety Valves for Superheaters and Reheaters {PG-68.6} n) Material Selection Cast Iron Seats and Disks {PG-73.3.1} o) Material Selection Adjacent Sliding Surfaces {PG-73.3.2} 230 p) Material Selection Bodies, Bonnets or Yokes, Nozzles, Disks, and Other Parts Contained within the External Structure {PG-73.3.3, with Note after PG-73.3.4} q) Material Selection Bronze Parts in Safety Valves or Safety Relief Valves {PG-73.3.4} r) Operation General Requirements {PG-72.1} s) Operation Popping Point Tolerances {PG-72.2} t) Operation Springs in a Pressure Relief Valve {PG-72.3}
u) Operation Replacement of Springs In Valves {PG-72.4} 9.5 Production Testing {Note at end of PG-73.4.4(b)(6)} a) Pressure Testing {PG-73.5.1} 1) {PG-73.5.1(a)} i) {PG-73.5.1(a)(1)} ii) {PG-73.5.1(a)(2)} 231 2) {PG-73.5.1(b)} 3) {PG-73.5.1(c)} 4) {PG-73.5.1(d)} 5) {PG-73.5.1(e)} 6) {PG-73.5.1(f)} b) Valves Tested with Steam by Manufacturers or Assemblers {PG-73.5.2} 1) {PG-73.5.2.1} 2) {PG-73.5.2.2} i) {PG-73.5.2.2.1}
ii) {PG-73.5.2.2.2} c) Leak Test {PG-73.5.3(a)} {PG-73.5.3(b)} d) Documentation for Application, Calibration and Maintenance of Test Gauges {PG-73.5.4} e) Steam Testing Time {PG-73.5.5} 232 f) Test Fixtures and Test Drum {PG-73.5.6} 9.6 Requirements to Obtain and Use Code Symbol Stamp a) ASME Inspection Requirements {PG-73.4.1} b) Timing of ASME Inspections {PG-73.4.2} c) Requirements for Applying the V Code Symbol {PG-73.4.3} 1) {PG-73.4.3(a)}
2) {PG-73.4.3(b)} 3) {PG-73.4.3(c)} 4) {PG-73.4.3(d)} d) Use of Code Symbol Stamp by an Assembler {PG-73.4.4} 1) {PG-73.4.4(a)} i) {PG-73.4.4(a)(1)} ii) {PG-73.4.4(a)(2)} iii) {PG-73.4.4(a)(3)} 233 (1) {PG-73.4.4(a)(3)(a)} (2) {PG-73.4.4(a)(3)(b)} 2) {PG-73.4.4(b)} i) {PG-73.4.4(b)(1)} ii) {PG-73.4.4(b)(2)} iii) {PG-73.4.4(b)(3)} iv) {PG-73.4.4(b)(4)} v) {PG-73.4.4(b)(5)} vi) {PG-73.4.4(b)(6)} 9.7 Installation Provisions a) Mounting Safety Valves on a Boiler
d) Spacing of Mufflers on Pressure Relief Valves and Shielding Pressure Relief Valves from Outdoor Elements {PG-71.1} b) Connecting Safety Valves on a Boiler {PG-71.2} c) Spacing Between Safety Valves and Boiler {First 3 paragraphs of PG-71.3} {PG-71.4} 234 e) Connection Spacing for a Boiler Fitted with Two or More Pressure Relief Valve on One Connection {PG-71.5} f) Attachment of Pressure Relief Valves to Drums or Headers {PG-71.6} g) Outlet Connections for Pressure Relief Valves on a Boiler {PG-71.7} h) Connection of Pressure Relief Valves Attached to a Separate Steam Drum or Dome {PG-71.8}
i) Power-Actuated Pressure Relieving Valves and Isolating Stop Valves for Forced-Flow Steam Generators with No Fixed Steam and Waterline, Equipped with Automatic Controls and Protective Interlocks Responsive to Steam Pressure {Last sentence of first paragraph of PG-67.4.1} {Second paragraph of PG-67.4.1} j) Location of Pressure Relief Valves for Superheaters {Second sentence of PG-68.1} {Last sentence of PG-68.1} 235 k) Location of Pressure Relief Valves for Reheaters {PG-68.4} l) Attachment of a Soot Blower Connection for Superheaters and Reheaters {PG-68.5}
Record 12-1151 Record Level Review and Comment Project Manager David Tuttle Record Sub-Type Revision Pages Subject BPV I; review PTFH-12 Proposal Revise the proposed overpressure protection rules in the new Part PTFH for Section I, paragraph PTFH-12. Explanation This item was requested at the May 2012 SC-SVR meeting as a response to BPV I item #10-854. The thermal fluid heaters do not contain water and steam as more conventional power boilers do; the fluids are similar to those covered by Part PVG, instead. However, the overpressure protection rules in PVG-12 are written for vapor only. When a PRV opens, a vapor expands nearly isentropically from the stagnant inlet conditions to the outlet pressure, usually atmospheric. The change in enthalpy results in a significant velocity at the outlet. Significant backpressure is developed when the PRV opens. The thermal fluid heaters contain liquid, not vapor. The liquid is usually hot, but under enough pressure to keep it in the liquid phase. When a PRV opens, the pressure in the liquid drops, again usually to atmospheric pressure, but the temperature is still high, producing flashing with vapor generation as the fluid moves through the PRV. The vapor generation reduces the mass flow capacity of the PRV and creates backpressure. The PRV cannot be selected based on liquid sizing rules. There are many methods for calculating capacities in two-phase service. But no PRVs have certified capacities for two-phase flow. Summary of Changes Revision to PTFH-12 by adding limitations for two-phase liquid/vapor relief. Item History Sub-Tier Committees Involved BPV SC-SVR SGGR Latest Ballot Information Ballot: 13-208 Ballot Level: Subcommittee Final Record Status :Disapproved Date Opened: 02/01/2013 Date Closed: 03/26/2013 236
Item 12-1151: Section I, Review of PTFH-12 SC-SVR History May 15, 2012 Mr. Tuttle reported that BPV I requested that SC-SVR review item #10-854. The subgroup concluded that it would be appropriate to open a new item for the review and allow the other language to move forward. This record has been opened for SC-SVR. Mr. Tuttle was assigned as the Project Manager and Mr. Burgess volunteered to be a member of the project team. August 14, 2012 Mr. Tuttle reported that this is a new Subpart for liquid phase heaters; this item is to review the overpressure protection section of that. This part is going to get into an area that Section I has avoided in the past, high-temperature high-pressure liquids. In this case, the liquid may not be hot enough to flash into steam which is the provision that the code used to operate under. Mr. Tuttle has requested assistance on this item because it is going to be a large task. November 6, 2012 Mr. Tuttle reported that this is a new part for BPV I. It is shown in the minutes as SVR received it however there is a revised version that will be uploaded to CS Connect and sill be sent for ballot after the meeting. February 12, 2013 This item is currently out for ballot to the subgroup. August 13, 2013 Mr. Ball reported that there was a review and comment ballot issued to SVR and Mr. Tuttle is working on responding to those comments. October 29, 2013-237
GENERAL Item 10-854 8-6-12 PART PTFH REQUIREMENTS FOR LIQUID PHASE THERMAL FLUID HEATERS PTFH-1 GENERAL The rules in Part PTFH are applicable to liquid phase thermal fluid heaters and parts thereof and shall be used in conjunction with the general requirements in Part PG as well as with the special requirements of this Part that apply to the method of fabrication used. PTFH-2 SCOPE These rules apply to closed loop liquid phase thermal fluid heaters (flooded pressure vessel) in which the heat transfer media is heated but no vaporization takes place within the vessel. Thermal fluids are fluids (other than water) that are chemically stable over a large temperature range and are specifically designed for use as heat transfer mediums. Depending on the fluid selection and operating parameters, systems may be open or closed to the atmosphere. Closed systems may be pressurized with an inert gas blanket. PTFH- 5 GENERAL MATERIALS PTFH- 5.1 Materials used in the construction of pressure vessel parts for liquid phase thermal fluid heaters shall conform to those permitted in Section I for which allowable stress values are given in Tables 1A and 1B of Section II Part D. Pressure relief valve materials shall conform to PG-73.3 PTFH- 5.2 The requirements for materials given in Part PG shall apply in all respects to liquid phase thermal fluid heaters. PTFH- 5.3 The Manufacturer is responsible for ensuring the selected materials are compatible with the intended thermal fluid service. DESIGN PTFH-8 GENERAL REQUIREMENTS PTFH- 8.1 The Manufacturer shall be responsible for providing a design which shall permit satisfactory and safe operation of the heater under all normal conditions of operation. PTFH- 8.2 The design of the heater shall take into consideration the recommendations of the manufacturer of the heat transfer media regarding the maximum allowable bulk fluid and film temperatures. PTFH- 9 APPURTENANCES & EXTERNAL PIPING PTFH- 9.1 Liquid phase thermal fluid heaters are intended to operate in a liquid state within a closed loop circulating system (the system may be pressurized or open to the atmosphere). The external piping associated with a liquid phase thermal fluid heater consists of (as a minimum) the required inlet and outlet connections for circulating the thermal fluid through heater, vent and drain connections (as applicable) and a pressure relief valve connection(s). (a) A high point vent or purge valve(s) shall be provided in either the heater or the connecting piping to ensure that all air has been exhausted from the heater and connected piping during filling and the pressure vessel and piping are completely flooded with the thermal fluid. (b) The closed loop operation of a liquid phase thermal fluid heater eliminates the need for a liquid make up feed system. A suitable low point drain shall be provided in the heater or connecting piping to allow the heat transfer media to be drained out of the pressure vessel when necessary. (c) External piping associated with liquid phase thermal fluid heaters shall be designed in accordance with the applicable requirements of ASME B31.1. All external piping connections to the liquid phase thermal fluid heater shall be attached as provided in PG-59.1.1.1, PG-59.1.1.2 and PG- 59.1.1.3 except that threaded connections larger than 1 inch NPT shall not be used. PTFH- 9.2 Welded or mechanically assembled heater external piping shall meet the requirements of PG-l04 for proper Code certification. PTFH- 9.3 The jurisdictional limits of heater external piping shall extend from the heater inlet and outlet connections up to and including the first stop valve (Fig. 9.3). When multiple heaters are connected to common supply and return piping and the heaters contain openings of a size that permit entry into the thermal fluid space of the pressure vessel, the inlet and outlet piping of each shall be equipped with two stop valves. Vent and drain connections attached directly to the heater shall be equipped with two in-line stop valves when the heater has a maximum allowable working pressure exceeding 100 psig (700 kpa). 238
PTFH- 10 PROVISIONS FOR THERMAL EXPANSION OF THE HEAT TRANSFER MEDIA PTFH- 10.1 Liquid phase thermal fluid heaters shall have provisions for the expansion of the heat transfer media with temperature. A closed loop system shall be equipped with a thermal expansion tank with a means for level indication to indicate and monitor changes in volume due to changes in fluid temperature during operation. (a) The volume of the expansion tank shall be consistent with the volume and capacity of the system. The minimum required expansion tank capacity shall be determined by calculating the volume of fluid in the heater and system and multiplying it by the coefficient of expansion at temperature of the heat transfer media being used. (b) Systems open to the atmosphere and designed to operate at static pressures at or below 15 psi (100 kpa) do not require a Code Stamped expansion tank or a pressure relief valve. The expansion tank shall be vented to the atmosphere and shall be installed with piping directing any fluid discharge or overflow to a safe point of discharge. (c) Systems that are closed to the atmosphere and systems that are designed to operate at static pressures above 15 psi (100 kpa) shall have an expansion tank constructed and stamped in accordance with Section VIII, Division 1. The expansion tank shall be equipped with a pressure relief valve in accordance with ASME Section VIII, Div. 1. The pressure relief valve shall be of a totally enclosed type and shall be installed with discharge piping directing any fluid to a safe point of discharge. (See PTFH-12.3) (d) The system shall have provisions for shut down of heat source to the heater in the event of a drop in fluid level in the expansion tank below the safe minimum level PTFH- 11 NON BOILER EXTERNAL PIPING - - - - - INSTRUMENTATION Fig. PTFH 9.3 PTFH- 11.1 Pressure Each liquid phase thermal fluid heater shall have a pressure gauge(s) so located that it is visible and easily read from the operating floor. The pressure gauge(s) or indicator(s) shall be installed so that it shall indicate the pressure in the heater at all times during operation. PTFH- 11.2 Temperature Each liquid phase thermal fluid heater shall have a temperature gauge or other instrumentation indicating the temperature of the fluid in the heater at or near the outlet connection from the heater. The temperature gauge or indicator shall be so located that it is visible and easily read from the operating floor at all times during operation PTFH- 11.3 Fluid Flow Each liquid phase thermal fluid heater shall have instrumentation that visibly indicates flow of the heat transfer media through the heater during operation. Instrumentation that monitors or indicates differential pressure across the heater or other device in the associated closed loop circulation system may be used. The instrumentation shall be so located that it is visible and easily read from the operating floor. The fluid flow instrumentation shall have provisions for shut down of the heat source to the heater in the event of an interruption or cessation of the fluid flow during operation. PTFH-12 OVER PRESSURE AND OVER TEMPERATURE PROTECTION PTFH- 12.1 It is the user or the designated agent s responsibility to identify all intended service conditions and operating parameters including any potential over pressure or over temperature scenarios. Intended service conditions shall include but are not limited to the following: (a) Conditions where the vapor pressure of the thermal fluid is greater than atmospheric pressure (14.7 psia [0.101 MPa) at the maximum operating temperature of the system and the boiling point temperature or temperature range of the thermal fluid is less than the maximum operating temperature of the system. (b) Conditions where the vapor pressure of the thermal fluid is less than atmospheric pressure (14.7 psia [0.101 MPa]) at the maximum operating temperature of the system and the boiling point temperature or temperature range of the thermal fluid is at or above the maximum operating temperature of the system. PTFH-12.2 Each liquid phase thermal fluid heater shall have at least one pressure relief valve. For heaters having more than 500 ft2 (47 m 2 ) of liquid heating surface or an electric heating capacity greater than 1,100 kw, two or more pressure relief valves shall be provided PTFH-12.3 The pressure relief valve(s) shall be of a totally enclosed type designed for liquid service. (a) The pressure relief valve(s) shall be installed with a discharge piping directing any fluid to a safe point of discharge. (b) The pressure setting shall be not higher than the MAWP stamped on the completed heater. (c) The pressure relief valve shall not have a lifting lever. (d) Valve body drains are not required. (e) The inlet connection to the valve shall be not less than NPS ½ (DN 15). (f) The discharge connection of the pressure relief valve shall be at least one NPS pipe size larger than the inlet. PTFH-12.4 The required relieving capacity for fired heaters shall be determined by Waiting for SC SVR 239
PTFH-12.5 The required pressure relieving capacity for unfired (electric heaters) shall be 3.5 Ib/hr/kW (1.6 kg/hr/kw) heat input. PTFH-12.6 The pressure relief valves shall be tested and certified as provided in PG-69. Sizing equations and capacity correction factors for a specific heat transfer fluid and application shall be in accordance with the fluid supplier s or relief valve manufacturer s recommendations or API Standard 520. Where the discharge from the pressure relief valve is 100% vapor, the rules of Part PVG shall be used for pressure relief valves. PTFH-12.7 The pressure relief valves shall be mounted as required by PG.71. PTFH-12.8 The Manufacturer shall ensure that the specified safety relief valves are suitable for the intended operating conditions of the liquid phase thermal fluid heater. PTFH-12.9 It is the responsibility of the user to insure that the pressure relief valve discharge piping required in Par. PTFH- 10.1(b) & (c) and PTFH-12.3(a) is properly installed prior to initial operation. The design of the pressure relief valve discharge piping shall take into consideration the potential for flashing, two phase flow, and possible backpressure in the discharge piping system during discharge of the thermal fluid. PTFH-12.10 Temperature Limiting Controls For fuel fired thermal fluid heaters, a manual reset over temperature device shall be used to monitor and limit the bulk temperature of thermal fluid to prevent overheating of the thermal fluid. PTFH-12.11 Temperature Limiting Controls For unfired (electric) thermal fluid heaters, a manual reset over temperature device shall be used to monitor and limit either the bulk temperature or the element sheath temperature to prevent overheating of the thermal fluid. 240
241
Record 12-1472 Record Level SC Proposal Project Manager Roger Danzy Record Sub-Type Revision Pages Subject Section VIII; Revision to the requirements of UG-126(c) Proposal Delete UG-126(c) and replace with new UG-136(g) New paragraph UG-136(g) to provide rules for when the set pressure can be changed, the authority to make the set pressure change, the requirement and authority to make and install a replacement nameplate, the conditions and authority to supply and install a replacement spring, testing requirements and CI oversite. Explanation Paragraph UG-126(c) provides for a set pressure change of a pressure relief valve that has been set and sealed by the manufacturer or assembler but allows for other parties to make set pressure adjustments which will require breaking the seals of the organization responsible for setting and testing the pressure relief valve. Paragraph UG-126(c) does not provide guideance in the event a replacement spring is required by the set pressure change. Paragraph UG-126(c) allows a manufacturers authorized representative or an assembler to make set pressure and spring replacements. The manufacturers authorized representative is not defined in the Code. An assembler may not necessarily have authority to apply the Mark to the valve being modified. There is no requirement for testing the pressure relief valve for leakage and there are no requirements for designated oversight of the set pressure adjustment or spring replacement. The proposal allows only the manufacturer or an assemble with authorization to apply the Mark to the valve to make set pressure adjustments and/or install a new spring. The proposal allows only the manufacture to supply a nameplate and/or spring. Note: No references within ASME Section VIII Div 1 for either UG-126(c) or UG-126(d) were noted. UG-126(d) can be retained as UG-126(d) or renamed to UG-126(c) withou an effect on the paragraph references within ASME Section VIII Division 1. Summary of Changes Delete paragraph UG-126(c) and add paragraph UG-136(g). Item History Sub-Tier Committees Involved BPV SC-SVR BPV SC-SVR SGD Latest Ballot Information 242
Item 12-1472: Section VIII; Revision to the requirements of UG-126(c) SC-SVR History November 6, 2012 This item is for changing the set pressure of a valve prior to putting it into service; it is a companion item to #09-1324. Section VIII revised and passed another item and we are now submitting this item to correct it. February 12, 2013 - Mr. Danzy reported that this is a companion to #09-1324. There was another item that went to Section VIII which was totally rewritten and BPTCS approved. This new item is to go back to BPV VIII with regards to changing the set pressure of the valve but is on hold pending SVR approval of the BPV I item #09-1324. August 13, 2013 Mr. Conley reported that they have a draft but are waiting on the Section I item before this item proceeds. October 29, 2013-243
244 12-1274 September 11, 2012 Page 1
12-1274 September 11, 2012 Page 2 UG-136(g) Set Pressure Change. (a)the set pressure of a valve may be changed after completion of the UV-1 form but prior to being put into service for overpressure protection provided all of the following conditions are met: (1) A new nameplate as described in UG-129 shall be furnished by the Manufacturer. The original nameplate shall be removed and the Manufacturer shall be responsible for the destruction of the original nameplate; (2) If the set pressure change requires a new spring, the spring shall be supplied by the Manufacturer; (3) Adjustments to the set pressure shall be performed per UG-136(d)(4); (4) Leak testing per UG-136(d)(5) shall be performed; (5) All adjustments, testing, installation of the nameplate and if required, installation of a new spring, shall be performed by the Manufacturer, or an Assembler that has been granted permission to apply the Certification Mark with "UV" Designator to the specific valve type. 245
Record 13-78 Record Level SC Proposal Project Manager Dean Miller Record Sub-Type Revision Pages Subject BPV Section VIII-3; move cautionary elements from the current manufacturing range definition Proposal remove the cautionary elements from the current manufacturing range definition and incorporate them into KR-200 Explanation to be added by PM Summary of Changes Item History Sub-Tier Committees Involved BPV SC-SVR SGD Latest Ballot Information 246
Item 13-78: Section VIII-3; BPV VIII-3; Move Cautionary Elements From the Current Manufacturing Range Definition SC-SVR History January 2013 This item was opened in response to a comment received during balloting of #01-061. February 12, 2013 Mr. Miller reported that this item results from an IOU on #01-061. Within the definition there is some cautionary application comments and it is felt that the definition should just be the definition and the cautionary statements should be moved to another location. This item is on hold until a copy of the 2013 edition is made available. August 13, 2013 Mr. Miller reported that this is an IOU from #01-061; nothing has been done with this item yet. October 29, 2013-247
Record 13-495 Record Level SC Approved Project Manager Dean Miller Record Sub-Type Code Case Pages Subject Code Case to delay implementation of record #01-061 Proposal Adopt a new Code Case to postpone the requirement for rupture disk devices to carry the ASME Certification Mark and applicable Designator as described in KR-200(a) until January 1, 2015 Explanation The 2013 Edition of ASME Section VIII, Division 3 will incorporate item 01-061 into the Code. This change requires all bursting disk devices used on Division 3 vessels to be marked with the ASME Certification Mark and applicable Designator. By default this requirement will become mandatory on January 1, 2014. This provides only six months for manufacturers to identify designs that are used on Division 3 vessels, submit application to the ASME Designated Organization and get production testing scheduled and performed. With some devices being manufactured by differing rupture disk and holder manufacturers this process will be even more time consuming. Since this item also includes the creation of new ASME Scopes of Authorization and there are many manufacturers of these devices it is very likely that many of the devices used today will not have completed the certification process by January 1, 2014. The objective of the Code Case is to delay the mandatory implementation of these requirements to allow manufacturers sufficient time to pursue the necessary device certifications and prevent users from being put in the position of having to knowingly violate Code rules by applying non-certified devices. Summary of Changes Item History SG-HPV (11/7/12): Proposal currently being balloted, 13-738, to SC-SVR. Proposal unanimously approved by SG-HPV. Sub-Tier Committees Involved BPV SC-SVR SGD Latest Ballot Information Ballot: 13-738 Ballot Level: Subcommittee Final Record Status :Approved Date Opened: 04/03/2013 Date Closed: 05/13/2013 248
Item 13-495: Code Case to Delay Implementation of #01-061 SC-SVR History February 12, 2013 Mr. Miller reported that this item is a byproduct of #01-061. It entails establishment of new scopes of authorization as well as a new process for manufacturers to have time to prepare and implement some of the devices. As written now, the code would require that all devices to be stamped on Jan 1, 2014 and this is to delay that mandate by one year. Mr. West requested that the proposal for this item be developed and balloted prior to the May BCW. August 13, 2013 Mr. Miller note that this ballot was approved by SC-SVR but is being held since item #01-061 was put on administrative hold and was not published in the 2013 edition. This item is going to continue to be held until #01-061 gets published to determine if this code case is needed; this item will be moved to items in progress on future agendas. October 29, 2013-249
Case XXXX Implementation of ASME Certification Mark and Applicable Designator. Section VIII, Division 3 Inquiry: In the 2013 Edition of the ASME Section VIII, Division 3 paragraph KR-200(a) adds a new requirement for rupture disk devices to carry the ASME Certification Mark with the applicable UD or UD3 Designator. May rupture disk devices for use on Division 3 vessels without the ASME Certification Mark continue to be used beyond the six-month period after which revisions to the Code published in the 2013 Edition become mandatory? Reply: It is the opinion of the Committee that the implementation of the requirement for rupture disk devices to carry the ASME Certification Mark and applicable Designator as described in KR-200(a) may be postponed until January 1, 2015. 250
Record 13-500 Record Level SC Proposal Project Manager J. Alton Cox Record Sub-Type Interpretations Pages Subject BPV I Inquiry Regarding Lift Assist Devices Proposal Explanation Sec. I, PG-73.5.2.2.2 permits Lift Assist Device Testing when the PRV Set Pressure is beyond the Production Test Equipment capabilities. PG-73.5.3 requires Leak Testing at expected Maximum Operating Pressure. If the Set Pressure is above Production Test Equipment Capabilities, the Leak Test Pressure may also exceed Production Test Equipment Capabilities. This item has been opened to address Leak Testing when a Lift Assist Device is used to determine Set Pressure. Summary of Changes Item History Sub-Tier Committees Involved BPV SC-SVR BPV SC-SVR SGT Latest Ballot Information 251
Item 13-500: BPV I Inquiry Regarding Lift Assist Devices SC-SVR History March 2013 Section I, PG-73.5.2.2.2 permits Lift Assist Device Testing when the PRV Set Pressure is beyond the Production Test Equipment capabilities. PG-73.5.3 requires Leak Testing at expected Maximum Operating Pressure. If the Set Pressure is above Production Test Equipment Capabilities, the Leak Test Pressure may also exceed Production Test Equipment Capabilities. This item has been opened to address Leak Testing when a Lift Assist Device is used to determine Set Pressure. August 13, 2013 Mr. Cox reported that he has added some information to the record but it is just a progress report and there is no proposed answer at this time. October 29, 2013-252
Colleen O'Brien From: Sent: To: Cc: Subject: SukKyu Myung(SVC) <nickmsk@smartvalve.com> Friday, February 08, 2013 12:55 AM Umberto D'Urso KiSung Jung(SVC); MoonKyu Bang(SVC) Regarding Lift Assist Device(LAD) Dear Sir, This is Suk-Kyu Myung a quality manager in SVC Inc. a Pressure Relief Valve manufacturer in Korea. I am writing this letter because I have a question about the use of Lift Assist Device(LAD). On PG-73.5.2.2, it says that LAD is available when pressure test is performed. However, on paragraph PG-73.5.3 Leak test there is no comment about LAD. I would like to know using LAD on Leak Test is available or not. If LAD is used because the valve is beyond the capability of the pressure test equipment, leak test could not be performed without LAD. Your prompt response will be highly appreciated. Thank you very much. Best regards, Suk-Kyu Myung. 주식회사 SVC 품질팀명석규부장 Tel : 031-983-2396 Mobile : 010-5288-4425 E-Mail : nickmsk@smartvalve.com 1 253
Record 13-661 Record Level SC Proposal Project Manager Alan West Record Sub-Type Revision Pages Subject Conformity Assessment Revisions Proposal Explanation The new CA-1 standards will be published soon and the conformity assessment requirements need to be removed from the BPVC Section.s This is a general item for the removal of the conformity assessment requirements from the safety valve requirements in each of the codes, separate items will be opened for each code as their need is determined. Summary of Changes Item History Sub-Tier Committees Involved BPV SC-SVR Latest Ballot Information 254
Item 13-661: Conformity Assessment Revisions SC-SVR History February 12, 2013 Mr. West reported that there is a CAR Committee which has generated a new book CA-1 which has taken all of the conformity assessment information from the separate code books and has put them into this one new book. They have asked each of the BPVC Standards Committees to open items to remove the conformity assessment requirements. This item is a general item to cover the conformity assessment requirements in the safety valve section; new items will be opened as their need in each section is identified. Alan and the secretary will discuss with each standards committee to determine whether they will be taking out items to remove the conformity assessment requirements in the safety valve sections or if we need items here. The CAR committee has also requested that SVR provide a new representative since Mr. Tuttle will no longer be serving in that position. The CAR committee meets on Wednesdays from 3-6pm during Boiler Code Week. Mr. Burgess and Mr. Danzy reported that they will be able to attend the meeting tomorrow. Mr. West will notify the chair of the CAR Committee that we are in the process of determining an SVR representative. August 13, 2013 SVR has submitted names and we are waiting to see which applicants the CAR Committee appoints. This item is also a placeholder to determine which codes will need SVR to remove CA requirements from the PRD sections. October 29, 2013-255
Record 13-663 Record Level SC Proposal Project Manager Alan West Record Sub-Type Object & Scope Pages Subject BPVC for Overpressure Protection Proposal Explanation This item is for the object and scope of a potential new Section to the ASME BPVC for Overpressure Protection Summary of Changes Item History Sub-Tier Committees Involved BPV SC-SVR Latest Ballot Information 256
Item 13-663: New BPVC Section on Overpressure Protection SC-SVR History TASK GROUP MEMEBRS: A. West (leader), F. Harrison, J. Ball, D. DeMichael, D. Miller, R. Danzy, A. Cox, T. Patel February 12, 2013 Mr. West reported that there is interest in making a push for a standalone book for overpressure protection. He indicated that he is going to put a proposal together pending confirmation from the subcommittee that there would be enough volunteers to work on this item. This will be a significant, long-term effort. Mr. Glaspie indicated that he is opposed to creating a separate book and that the requirements should remain in the original code of construction; there are already too many books to follow. Mr. Ball noted that if this does go forward, it would need to be dictated to the other code sections that they would need to remove the overpressure protection requirements from their codes. Mr. Harrison indicated that he is in favor of a separate book but the first step with the business plan is to determine which categories of requirements will remain in the construction codes and which will go in this new section. A straw vote was taken to determine the favor of the committee. Messer s Harrison, Burgess, Hart, Wang, DeMichael, Miller and Danzy are in favor of the new book. Mr. Glaspie maintains his disapproval because he feels that this would not be in the best interest of the user because they would need to purchase multiple books. Volunteers are needed for assisting with the development of the business plan. The Task Group will meet via teleconference to work on the business plan proposal. Mr. West will be the lead and the PT will consist of Messer s Harrison, Ball, DeMichael, Miller, Danzy and Cox. August 13, 2013 Mr. West reported that the task group has drafted a prosed business case for the new book. Mr. West requested that the proposal be circulated to the committee via email for review and comment. Any feedback for Mr. West should be provided by August 30, 2013. MOTION was made to incorporate the comments and to send the proposal for a letter ballot as soon as possible. Mr. West noted that there will likely need to be another TG teleconference after the comment period. The proposal will then be revised and the CS Connect ballot will be sent. The motion was seconded and approved. Mr. Patel requested to be added as a member of the project team. October 29, 2013-257
Record 13-729 Record Level SC Proposal Project Manager J. Alton Cox Record Sub-Type Revision Pages Subject BPV IV; HG-402.3(a) Maximum Allowable Coefficient Proposal Explanation Section IV paragraph HG-402.3(a) never incorporated the maximum permitted coefficient of 0.878. This requirement was part of the 1976 version of PTC-25, but taken out of PTC-25 in the 1988 version when the book codes were to adopt it. This maximum coefficient of 0.878 is published in Section I para. PG-68.2.3(b) and Section VIII para. UG-131(e)(2). The change is needed to restore consistency among the codes. Summary of Changes Add the requirement of the maximum coefficient of 0.878 (0.9 x 0.975). Item History Sub-Tier Committees Involved BPV SC-SVR BPV SC-SVR SGT Latest Ballot Information 258
Item 13-729: HG-402.3(a) Maximum Allowable Coefficient SC-SVR History August 13, 2013 Mr. Cox will be updating the background for this item and a request will be sent to the secretary to initiate the ballot. October 29, 2013-259
2013 SECTION I 260 For nozzle (US. CUsromary Units) Wr = Sl.SAP (Sf Units) Wr = S.2SAP For tests with water For 45 deg seat (US. CUsromary Units) (Sf Units) For Rat seat (US. CUsromary Units) (Sf Units) For nozzle Wr = 2, 4{)7 rrdl (0.707)J (P - Pd)w Wr = 5.092 rrdl (0.707)J (P - Pd)w To convert lbfhr of water to gal/min of water, multiply the capacity in lbfhr by 1 /sor> To convert kgjhr of water to liter /min of water, multiply the capacity in kgfhr by '!... The average of the coeffidents K 0 of the nine tests required shad be multiplied by 0.90, and this product shad be taken as the coefficient K of that design. All individual coefficients of discharge, K 0, shall fall within a range of t5% of the average coefficient found. If a valve fails to meet this requiremen~ the Authorized Observer shall require two additional valves to be tested as replacements for each valve having an individual coefficien~ K 0, outside the t5% range, with a limit of four additional valves. Failure of a coellicien~ K 0, to fall within t5% of the new average value, excluding the replaced valve(s), shall be cause to refuse certification of that particular valve design. The rated relieving capacity of all sizes and set pressures of a given design, for which K has been established under the provision of this paragraph, shall be determined by the following equation: where w $ Wr x K K = coefficient of discharge for the design W = rated relieving capacity, lbfhr (kgfhr) W 7 = theoretical flow, defined by the same equation used to determine K 0, lbfhr (kgfhr) The coefficient of discharge for the design shall be not greater than 0.878 (the product of 0.9 x 0.975). The coefficient shall not be applied to valves whose beta ratio (ratio of valve throat to inlet diameter) lies outside the range of0.15 to 0.75, unless tests have demonstrated that the individual coefficient of discharge, K 0, for valves at the extreme ends of a larger range, is within t5% of the
2013 Edition, Section IV, HG 402.3 The coefficient of the design shall not be greater than 0.878 (the product of 0.9 X 0.975). 261